ML20151L515

Monthly Operating Repts for Mar 1988

ML20151L515
Person / Time
Site:	Quad Cities
Issue date:	03/31/1988
From:	Deelsnyder L, Robey R COMMONWEALTH EDISON CO.
To:	NRC OFFICE OF ADMINISTRATION & RESOURCES MANAGEMENT (ARM)
References
RAR-88-14, NUDOCS 8804220070
Download: ML20151L515 (22)

Text

C .

QUAD-CITIES NUCLEAR P0HER STATION UNITS 1 AND 2 MONTHLY PERFORMANCE REPORT MARCH, 1988 COMMONHEALTH EDISON COMPANY AND IONA-ILLIN0IS GAS & ELECTRIC COMPANY NRC DOCKET NOS. 50-254 AND 50-265 LICENSE NOS. DPR-29 AND DPR-30 j.

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s.., 8804220070 880331 7!

) PDR ADOCK 05000254  !

R DCD E 0027H/0061Z

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TABLE OF CONTENTS I. Introduction II. Summary of Operating Experience A. Unit One B. Unit Two III. Plant or Procedure Changes, Tests, Experiments, and Safety Related Maintenance A. Amendments to Facility License or Technical Specifications B. Facility or Procedure Changes Requiring NRC Approval C. Tests and Experiments Requiring NRC Approval D. Corrective Maintenance of Safety Related Equipment IV. Licensee Event Reports V. Data Tabulations A. Operating Data Report B. Average Daily Unit Power Level C. Unit Shutdowns and Power Reductions VI. Unique Reporting Requirements A. Main Steam Relief Valve Operations B. Control Rod Drive Scram Timing Data VII. Refueling Information VIII. Glossary I

0027H/0061Z l

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I. INTRODUCTION Qucd-Cities Nuclear Power Station is composed of two Boiling Water Reactors,.each with a Maximum Dependable Capacity of 769 MWe Net, located in Cordova, Illinois. The Station is jointly owned by Commonwealth Edison Company and Iowa-Illinois Gas & Electric Company. The Nuclear Steam Supply Systems are General Electric Company Bolling Water Reactors. The

-Architect / Engineer was Sargent & Lundy, Incorporated, and the primary construction contractor was United Engineers & Constructors. The Mississippi River is the condenser cooling water soccce. The plant is subject to license numbers DPR-29 and DPR-30, issued October 1, 1971, and March 21, 1972, respectively; pursuant to Docket Numbers 50-254 and 50-265. The date of initial Reactor criticalities for Units One and Two, respectively were October 18, 1971, and April 26, 1972. Commercial generation of power began on February 18, 1973 for Unit One and March 10, 1973 for Unit Two.

This report was compiled by Verna Koselka and Lynne Deelsnyder, telephone l

number 309-654-2241, extensions 2240 and 2185.

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XI.

SUMMARY

OF OPERATING EXPERIENCE A. Unit One March 1-31 Unit One began the month operating.at full power. On March 2 at 1930, a load reduction to 445 MWe was taken due to problems with the IB Recirculation Motor-Generator (MG) Set. Repairs were made within a few hours and an ascension to full power was taken on March 3 at 0120 and held until March 8.

At 1016, the unit was placed and remained in Economic Generation Control (EGC) until March 12. At 2105, the unit was taken off of EGC due to problems with the MG Set controller. Instrument Maintenance made adjustments.to the master controller and abnormal speed indications on the recire MG set were resolved. At 2335, a load reduction to 750 MWe was taken for a reactor feed pump changeover. On March 13 at 0050, power levels were adjusted and Unit one was placed in EGC. On March 14 at 1555, the unit was taken off of EGC as a result of erratic feedwater heater levels. Adjustments were made and the unit was placed back in EGC on March 15 at 0110. At 0610, the unit was tripped out of EGC due to continued problems with the EGC master controller.

At 0805, a load reduction was made with control rods. A work request was initiated and Instrument Maintenance was notified. At 0915, the load dispatcher requested full load. At 0930, the unit reached 819 MWe. At 1810, problems were resolved concerning the master controller and power level was decreased from 817 MWe to 800 MWe in preparation for EGC operation. Consequently, j the unit remained in EGC for only a short duration when difficulties recurred with the master controller. At 1915, Unit 1 was ramped to full power until March 16. At 1233, a load drop was begun in preparation for EGC operations.

At 1246, the unit was placed in EGC where it remained until March 17 when a power level reduction was required to perform quarterly surveillances.

After surveillances were completed, a power level was increased to full load.

At 2130, load reduction was taken, and at 2152 Unit 1 was placed in EGC.

l The unit remained in EGC until March 18 at 1435 when functional testing was performed by Instrument Maintenance. At 0250 on March 19, while performing a l routine surveillance, it was discovered that the 1A main steam isolation valve would not partially close. Ar a result, at 0530 a load reduction was l taken to 600 MWe. Upon investigation, this time requirement for closure was increased by a modification put in during the last outage which changed the logic increasing the time for the valve to reach 90% open. At 0825, power level was increased to full load. At 1805, power level adjustments were made and unit was placed in EGC where it remained until March 23. At 0245, a load reduction was taken at the load dispatcher's request. At 0600, a power increase was taken from 575 MWe te full load. At 1644, power level adjustments were made and the unit was placed in EGC. The unit remained in ECC until 0515 on March 24 when power level was increased to full load. A full load capability test was performed. When completed, the unit was placed back in EGC where it remained until March 26. At 1305, the 1A recirculation pump tripped due to an oil cooler problem. Pump speed on the IB recirc pump and rod adjustments were nade in preparation for restarting the 1A pump. At 1413, the 1A pump was restarted and load increase was begun. At 1727, the unit was placed in EGC.

l The unit remained in EGC until 1140 on March 28 when power level was increased I to full load for TIP (traversing incore probe) set. Unit remained at full power l until March 29 at 2215, when a load reduction was taken for a monthly surveillance on control valves. At 0130 on March 30, a load increase was taken in preparation j for EGC. Unit was placed in EGC at 0220 where it operated for the remainder of the month.

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B. Unit Two March 1-31 Unit Two began operations for the month of March in Economic Generation Control (EGC). The unit remained in EGC with minor interruptions to perform routine surveillances until March 4. At 1240, a high DP alarm was received on the 2A and 2B travelling screens. Backpressure was increasing and the unit was taken off of EGC and a load reduction was taken to 560 MWe at 1305. Upon investigation, the 2A circulating water pump was found to be cavitating and the pins were discovered sheared on the 2A and 2B travelling screens. Fish had accumulated on the circ water screens and bays. Another. load reduction was taken to 410 MWe at 1340.' At 1345, condenser flow was reversed and unit backpressure appeared to be improving. At 1450, a load reduction was taken to 200 MWe for further investigation. This power level was held while repairs were made to the travelling screens and cire water pumps. After all problems were resolved, a power level increase was begun at 1800. At 1900, load was held at 400 MWe while control rod pattern adjustments were made. This power.

level was held until March 7. At 0800, load was held at 800 MWe while routine surveillances were performed. On March 8, power levels were adjusted in preparation for EGC operation and at 1546 the unit was placed in EGC. The unit remained in EGC with minor interruptions to perform surveillances until March 10. At 0045, the unit was taken off of EGC due to a steam leak on the 2C3 heater extraction piping. A load reduction was taken to 655 MWe and the 2C3 heater was taken out of service while maintenance performed repairs.

At 1240, the problem was resolved and a load increase was begun. At 1645.

Unit Two was placed in EGC and remained here until March 19. At 2343, the unit was taken off of EGC due to a packing leak on the "B" Feedwater Reg Valve. On March 20 at 0045, steam was discovered on the turbine floor, coming from the Unit 2 mezz level. Numerous fire alarms were received in the control room and the recire pumps were ramped to minimum speed. At 0055, the "B" Feedwater Reg Isolation Valve was closed and load was increased to 500 MWe. At 0110, numerous alarms were again received in the control room and at 0123, a reactor scram occurred on Unit 2 due to a turbine / generator i

load mismatch. This scram occurred as a result of the 2B Feedwater Reg i

Valve leaking water onto instrumentation and equipment that initiated the spurious trip. The unit remained shutdown on March 20 and 21 while the

packing was replaced on the 2B Feedwater Reg Valve. At 2345 on March 20, l the mode switch was placed in STARTUP, reactor head vents were shut and control rod withdrawal was begun. The reactor was critical at 0427 on March 21.

At 1313, the mode switch was placed in RUN and the generator was synchronized to the grid at 1545. A power ascent was begun using control rods and recirc pumps. 700 MWe was reached at 0015 on March 22. This power level was held until 0600 when a load increase to 740 MWe was taken. This power level was held until 1310 on March 23 when power level adjustments were made and Unit 2 l

was placed in EGC. From March 23 to March 29 the unit remained in EGC with

! brief interruptions to perform routine surveillances. At 0848, the unit was taken off of EGC and load was held at 773 MWe to perform a TIP set (traversing incore probe). At 1435 on March 30, the unit was placed back in ECC and operated here for the remainder of the month.

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r III. PLANT OR PROCEDURE CHANGES. TESTS, EXPERIMENTS, AND SAFETY RELATED MAINTENANCE A. Amendments to Facility License or Technical Specifications Technical Specification Amendment Nos. 105 and 101 were issued on March 8, 1988, to Facility Operating Licenses DPR-29 and DPR-30.

These amendments revise the Technical Specifications Table 3.2-4 of Appendix A. "Pust Accident Monitoring Instrumentation Requirements" to specify an expanded range for drywell pressure recorders.

B. Facility or Procedure Changes Requiring NRC Approval There were no Facility or Procedure changes requiring NRC approval for the reporting period.

C. Tests and Experiments Requiring NRC Approval There were no Tests or Experiments requiring NRC approval for the reporting period.

D. Corrective Maintenance of Safety Related Equipment The following represents a tabular summary of the major safety related maintenance performed on Units One and Two during the reporting period. This summary includes the following: Work Request Numbers, Licensee Event Report Numbers, Components, Cause of Malfunctions, Results and Effects on Safe Operation, and Action Taken to Prevent Repetition.

0027H/0061Z

2 UNIT 1 MAINTENANCE

SUMMARY

WORK REQUEST NO.: Q58887 LER NUMBER: .N/A COMPONENT: System 1600 - Replaced butt splices with window splices and heat shrinked on 1-1641-5A.

' CAUSE OF MALFUNCTION: Due to the lack of documentation, it was not known that transmitters 1-1641-5A and 1-1641-5B had nonenvironmentally qualified splices.

RESULTS-& EFFECTS ON SAFE OPERATION: Even though the splice configuration was not qualified, it was determined (by the Station Nuclear Engineering Department)

- that the transmitters would have performed their intended safety function during a postulated accident.

ACTION TAKEN TO PREVENT REPETITION: The immediate corrective action was to replace the butt splices with window splices and install Raychem Heat Shrink over them.'

The lack of documentation has been addressed in the "Environmental Qualification (E.Q.) Maintenance History File and Trending Program".

WORK REQUEST NO.: Q58888 LER NUMBER: N/A COMPONENT: System 1600 - Replaced butt splices with window splices and heat shrinked on 1-1641-5A.

CAUSE OF MALFUNCTION: Due-to the lack of documentation, it was not known that l

transmitters 1-1641-5A and 1-1641-5B had nonenvironmentally qualified splices.

RESULTS & EFFECTS ON SAFE OPERATION: Even though the splice configuration was not qualified, it was determined (by the Station Nuclear Engineering Department) that the transmitters would have performed their intended safety function during a postulated accident.

ACTION TAKEN TO PREVENT REPETITION: The immediate corrective action was to replace

[

the butt splices with window splices and install Raychem Heat Shrink over them.

The lack of documentation has been addressed in the "Environmental Qualification (E.Q.) Maintenance History File and Trending Program".

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UNIT 2 MAINTENANCE

SUMMARY

WORK REQUEST NO.: Q61439 LER NUMBER: N/A COMPONENT: System 8800 - Rebuilt solenoid valve for 2-8803.

CAUSE OF MALFUNCTION: The cause of the failure of the A0-2-8803 was the age of the o-rings allowing air to blow by the solenoid.

RESULTS & EFFECTS ON SAFE OPERATION: The A0-2-8803 is part of a double isolation.

The other valve being A0-2-8804 which did close properly thereby providing adequate containment isolation.

ACTION TAKEN TO PREVENT REPETITION: The solenoid valve was rebuilt for A0-2-8803 and an evaluation of similar solenoid problems is being done for incorporation into a Preventative Maintenance Program.

WORK REQUEST No.: Q61499 LER NUMBER: 87-016 COMPONENT: System 1300 - Aux contacts replaced on breaker and new T-bar installed for valve 2-1301-16.

CAUSE OF MALFUNCTION: The cause of the malfunction of the RCIC valve, 2-1301-16, to close was the result of auxiliary contact binding in the 480 volt contactor associated with this valve.

RESULTS & EFFECTS ON SAFE OPERATION: As the HPCI System was proven operable while the RCIC System was inoperable the safety significance is minimal.

ACTION TAKEN TO PREVENT REPETITION: The immediate corrective action was to replace the auxiliary contact like for like and install a new movable contact support T-bar. As this has been a previous problem, Action Item Record (AIR) 4-87-6 has been initiated.

IV. LICENSEE EVENT REPORTS The following is a tabular summary of all licensee event reports for Quad-Cities Units One and Two occurring during the reporting period, pursuant

-to the reportable occurrence reporting requirements as set forth in sections

-6.6.8.1. and 6.6.8.2. of~the Technical Specifications.

UNIT 1 Licensee Event Report Number Date Title of Occurrence 88-007 3-1-88 SBGT inoperable due to plastic bag draped over suction bell.88-006 3-25-66 Weekly Power Operational Functional Test performed late.

UNIT 2 38-003 3-1-88 RCIC inoperable - could not achieve flow and pressure.88-004 3-8-88 APRM BP'd with non-companion.

IRM already bypacsed.88-005 3-20-88 Reactor scram.

0027H/0061Z

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e V. DATA' TABULATIONS The following data tabulations are presented in this report:

A. Operating Data Report B. Average Daily Unit Power Level C. Unit Shutdowns and Power Reductions 1

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APPEN0lX C OPERATING DATA REPORT OOCKET NO. 50-254 UNIT One DATE April 7, 1988 COMPLETED BY L. Deelsnyder TELEPHONE 309-654-2241 l OMR ATING STATUS 0000 030188 2400 033188 744

1. REPORTING PERIOD: GROSS HOURS IN REPORTING PERIOO:

2. CURRENTLY AUTHORIZED POWER LEVELIMWty 2511 MAX. DEPEND. CAPACITY (MvMeeti: 769 DESIGN ELECTRICAL MATING (MWeNet): 709 N/A ,

3. POWER LEVEL TO WHICH RESTRICTED (IP ANYI (MWeNet):

4. REASONS POR RESTRfCTION (IP ANYli THIS MONTH YR TO DATE CUMULATivt 744.0 2184.0 111248.3_

5. NUM0ER OF HOURS REACTOR WAS CRITICAL , . . . . . . . . . . . . . .

0.0 0.0 3421.9

8. R EACTOR RESERVE SHUTOOWN HOL'RS . . . . . . . . . . . . . . . . . . .

744.0 2177.1 107635.3-

7. HOURS GEN ER ATOR ON LINE . . . . . . . . . . . . . . . . . . . . . . .

0.0 0.0 909.2-S. UNIT RESERVE SHUTOOWN HOURS . . . . . . . . . . . . . . . . . . . . . .

5193055 228533812

9. GROSS THERMAL ENERGY GENERATED (MWH) ..............I790359 586941 1699236 74122738.

10. GROSS ELECTRICAL ENERGY GENER ATED (MWHI . . . . . . . . . . . . .

560923 1625739 695290?8

11. NET ELECTRICAL ENERGY GENERATED (MWH1 . . . . . . . . . . . . . .

100.0 100.0 79.9

12. r E ACTOR SE RVICE P ACTOR . . . . . . . . . . . , . . . . . . . . . . ....

100,0 100.0 A2.3

13. R E ACTOR AV AILA BILITY P ACTOR . . . . . . . . . . . . . . . . . . . . . . .

100.0 99.7 77.3

14. U NIT S E RVIC E P ACT OR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

100.0 99.7 77.9_

15. UNIT AVAILAt i LITY P ACTOR . . . . . . . . . . . . . . . . . . . . . . . . . .

98.0 96.8 64.9

16. UNIT CAPACITY P ACTOR (Using MDC) .....................

.6  %.3 O,3

17. UNIT CAPACITY P ACTOR (Uung Oseign MWel . . . . . . . . . . . . . . . . .

0.0 0,3 5.3

18. UNIT PO RCEO OUT AG E RATE . . . . . . . . . . . . . . . . . . . . . . . . . .

19. SHUTOOWNS SCHEDULED OVER NEXT S MONTHS (TYPE. DATE. AND OURATION OF EACHl:

20. IP SHUT OOWN AT END OP REPORT PERf00. ESTIMATED DATE OP STARTUP:

PORECAST ACHIEVED

21. UNITS IN TEST STATUS (PRIOR TO COMMERCf AL OPERATIONi:

INITI AL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERATION 1.16 9 '

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APPENDlX C OPERATING DATA REPORT DOCK ET NO. 50-265 UNIT Two DATE April 7, 1988 COMPLETED BY L. Deelsnyder TELEPHONE 309-654-2241 l

OPERATING STATUS 0000 030188 2400 033188 GROSS HOUR $ 1N REPORTINC PERICO:

744

1. AEPORTING PERIOD:

2511 MAX. DEPEND. CAPACITY (MWe Noti. 769

2. CURRENTLY AUTHORIZED POWER LEVEL (WWtit DESIGN ELECTRICAL RATING (MW> Hot): M

3. POWER LEVEL TO WHICH RESTRICTED (IP ANY) (MWe. Net):

N/A ,

4. REASONS POR RESTRICTION llP ANY1:

THIS MONTH YRTODATS CUMULATIVE 716. 9 2060.9 106718.0 S. NUMGER OF HOURS REACTOR WAS CRITICAL . . . . . . . . . . . . . .

8. REACTOR RESERVE SHUTDOWN HOUfq8 . . . . . . . . . . . . . . . . . . .

O.0 0.0 2985.8_

2033.5 103568.8 T. HOURS GENER ATOR ON LINE . . . . . . . . . . . . . . . . . . . . . . . . . 7 0 5. 6 0.0 0.0 702.9 E. UNIT R E3ERVE SHUTDOWN HOURS . . . . . . . . . . . . . . . . . . . . . .

4648671 222019238

9. GROSS THERMAL ENERGY GENER ATED (MWH) ............. 1552695 502634 1507)20 71064904_

( 10. GROSS ELECTRICAL ENERGY GENER ATED (MWH1. . . . . . . . . . . . .

481847 1444891 67004916

11. NET ELECTRICAL ENERGY GENERATED (MWHI . . . . . . . . . . . . . .

96.4 94.4 77,1 l 12. r EACTOR SE RVICE P ACTOR . . . . . . . . . . . . . . . . . . . . . . . . . . .

96.4 94.4 79.2

13. R EACTOR AV AILA BILITY P ACTOR . . . . . . . . . . . . . . . . . . . . . . .

94.8 93.1 74.8 l 14. UNIT SERVICE P ACTOR . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .

94.8 93,1 75.1

15. UNIT AVAILABILITY P ACTOR 84.2 86.0 62.9

16. UNIT CAPACITY P ACTOR (Using MOC1 . . . . . . . . . . . . . . . . . . . . .

. .9 61.3

17. UNIT CAPACITY PACTOR (U$ sat Desip MWel . . . . . . . . . . . . . . . . .

5.2 6.9 ,

8.3 I 18. UNif PORCE D OUTAGE RATE . . . . . . . . . . . . . . . . . . . . . . . . . .

19. SHUTDOWNS SCHEDULE 0 CVER NEXT 6 MONTHS (TYPE. DATE. AND OURATION QP EACHl:

20. IP SHUT DOWN AT END OP REPO.9T PERICO. ESTIMATED DATE OP STARTUP:

21. UNITS IN TEST STATUS (PRIOR TO CCt.tMERCI AL OPERATION): PORECAST ACHIEVED INITI AL CRITICALITY INITIAL ELECTRICITY COMMERCIAL OPERAT1ON l

l 1.16 9 l

. APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-254 UNIT one DATE April 6 1988 COMPLETED BY L. Deelsnyder TELEPHONE 309-654-2241 MONTH MARCH 1988 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL ~

(MWe-Net) (MWe-Net) 9 780 17 783 732 gg 736 3

804 jg 756 3

4 20 -

767 724 5 21 g 811 700 22 y 776 710 23 g 758 756 24 g 767 3 730

. 746 691 10 3 gg 758 27 734 12 761 3 769 762 29 781 13 762 725 .

14 3 770 gj 741 15 l

16 758 INSTRUCTIONS On this form, list the average daily unit power level m MWe Net for each day in the reporting month. Compute to the neassst whole megawatt.

These figures will be used to plot a graph for cash reporting month. Note that when maximum dependable capacity is used for the nel clestncal rating of the unit, there may be occasions wher the daily average power level exceeds the 1004 line (or the restncted power lesel line). In such cases. the average daly unit power output sheet should be footnoted to caplaua the apperant anomaly.

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. APPENDIX B AVERAGE DAILY UNIT POWER LEVEL DOCKET NO. 50-?65 UNIT Two DATE April 6, 1988 _

COMPLETED BY L Deelsnvder TELEPHONE 309-654-2241 MONTH MARCH 1988 DAY AVERAGE DAILY POWER LEVEL DAY AVERAGE DAILY POWER LEVEL (MWe Net) (MWe-Net) 1 741 17 712 3 738 gg 700 3

761 gg 722 4 519 y 11 5

404 21 101 431 22 729 8

y 674 707 23 3

740 24 706 g 750 g 703 698 697

! 10 26

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qj 700 698 27 703 g 717 12

! 13 706 3 711 14 707 30 7II

• 702 709 15 33 16 703 1

INSTRUCTIONS On this form, list the average dady unit power level in MWe. Net for each day in the reporting rnonth Compute to the neancst whole megawatt.

These figures will be used to plot a graph for cash reporung month. Note that when maximum dependable capacity is used for the net cleetncal rating ut the unit, there may be oscasions when the daily average power level exceeds the l 100J line (or the restruted power Icset kne). In such cases. the average daily unit power output theet should be l footnoted to czplaua the apparent anomaly, l.l M l

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ID/SA APPENDIX D QTP 300-S13

• UNIT SHITTDOWNS AND POWER REDUCTIONS Revision 6 DOCKET NO. 50-265 August 1982 -

UNIT NAME QUAD CITIES UNIT TWO COMPLETED BY L. DEELSNYDER

• DATE _AP_RIL 7, 1983 REPORT NONTH MARCH. 1988 TELEPHONE 309-654-2241

_W e7a' N $ g w" 5

$EU O gw Ww

$ LICENSEE m@ g@

w DURATION g EVENT $" o NO. DATE (HOURS)

REPORT NO.

CORRECTIVE ACTIONS /COtetENTS 88-3 880304 --

0.0 H 9 HF ZZZZZZ Power Reduction Due to Condenser ?roblems Resulting from Accumulation of Fish on

, Circ Water Screens & Bays 88-4 880320 F 38.4 A 3 2-88-015 IA VAT.VFS Reactor Scram Due to Packing Leak on "B" Feedwater Reg Valve - While attempting to isolate, water fell onto instrumentation that initiated turbine trip.

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APPROVED AUG 161982 (final)

y. C. O S N

VI. UNIQUE REPORTING REQUIREMENTS.

i The following items are included in this report based on prior commitments to the commission:

A. MAIN STEAM RELIEF VALVE OPERATIONS There were no Main Steam Relief Valve Operations for the reporting period.

B. CONTROL ROD DRIVE SCRAM TIMING DATA FOR UNITS ONE AND TWO There was no Control Rod Drive Scram Timing Data-for Units One and Two for the reporting period.

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VII. REFUELING INFORMATION-T The following information about future reloads at Quad-Cities Station was requested in a January 26, 1978, licensing memorandum (78-24) from D. E.

O'Brien to C. Reed, et al., titled "Dresden, Quad-Cities, and Zion Stapion--NRCRequestforRefuelingInformation",datedJanuary 18, 1978.

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0027H/00612

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• ' QTP 300-532

' R; vision 1 QUAD-CITIES REFUELING March 1978 INFORMATION REQUEST

1. Unit: Q1 Raioad: 9 Cycle: _ _ _ to

2. Scheduled date for next refueling shutdown: 6-24-89

3. Scheduled date for restart following refueling: 9-17-89

4. Will refueling or resumption of operation thereaf ter require a technical spect fication change or other license amendment:

NOT AS YET DETSRMINED.

5. schedulad date(s) for submitting proposed licensing action and supporting information:

MARCH 24, 1989

6. Important IIconsing considerations associated with refueling, e.g., new or

' dif ferent fuel design or supplier, unreviewed design or performance analysis methods, significant changes in fuel design, new operating procedures:

NONE AT PRESENT TIME.

7. The number of fuel assemblies.

a. Nueber of assemblies in core: 724

b. Number of assemblies in spent fuel pool: 1773

8. The present licensed spent fuel pool storage capaclay and the size of any increase In licensed Storage capacity that has been requested or is planned in number of fuel assemblies:

a. Licensed storage capacity for spent fuel: 3657

b. Planned increase in licensed storage: , 0 9 The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity: 2008 APPROVED APR 2 01978 Q. C. O. S. R.

QTP 300-532 Revision 1 QU?.D-CITIES REFUFLlHG March 1970 li! FORMATION REQUEST

( .-

1. Unit: 02 Rcload:

f .,

__ _ 8 _ _ Cycle: _ 9_

f 2. Scheduled dets for nsxt refueling shutdown:

___,,,-9-88 4

3.

- Scheduled dats for r6 start following refueling: 6-18-88 4.

Will refueling or resumption of operation thereaf ter require a technical speelficattoo change or other license amendment:

YES. TECHNICAL SPECIFICATION CHANGES WILL BE REQUIRED FOR NEW FUEL TYPES (MAPHLGR CHANGE TOCURVES).

MCPR LIMIT AND OPERATION AT INCREASED CORE FLOW / FINAL FEEDWATER 5.

Scheduled Information:date(s) for submitting proposed licensing action and supporting March 4, 1988

6. Important licensing considerations associated with refyeling, e.g., new or

' dif ferent fuel design or supplier, unreviewed design er performance analysis methods, significant changes in fuel design, new operating procedures:

FIRST RELOAD OF GENERAL ELFCTRIC, GE8E FUEL WITH 4 WATER-RODS AND LHGR LIMIT OF 14.4 KW/FT.

l l 7. The number of fuel assemblies.

a. Number of assemblies in core: 724

b. Number of assemblies In spent fuel pool: 1311 8.

The present licensed spent fuel pool storage capacity and the size of any increase in licensed storage capacity that has been requested or is planned in number of fuel assemblies:

a. Licensed storage capacity for spent fuel:

3897

b. Planned increase in licensed storage:

0 9.

The projected date of the last refueling that can be discharged to the spent fuel pool assuming the present licensed capacity: 2008 1

/V P P R C) V E [>

APR 2 01978 Q. c. o S. R.

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VIII. GLOSSARY The following abbreviations which may have been used in th? Monthly Regior',,

are defined below:

ACAD/ CAM - Atmospheric Containment Atmospharic Dilution / Containment Atmospheric Monitoring ANSI - American National Standards Institute APRM - Average Power Range Monitor ATHS - Anticipated Transient Without Scram BHR - Boiling Hater Reactor CRD - Control Rod Drive EHC - Electro-Hydraulic Control System EOF - Emergency Operations Facility GSEP - Generating Stations Emergency Plan HEPA - High-Efficiency Particulate Filter HPCI - High Pressure Coolant Injection System HRSS - High Radiation Sampling System IPCLRT - Integrated Primary Containment Leak Rate Test IRM - Intermediate Range Monitor ISI - Inservice Inspection LER - Licensee Event Report LLRT -

Local Leak Rate Test LPCI - Low Pressure Coolant Injection Mode of RHRS LPRM - Local Power Range Monitor MAPLHGR - Maximum Average Planar Linear Heat Generation Rate MCPR - Minimum Critical Power Ratio MFLCPR - Maximum Fraction Limiting Critical Power Ratio MPC -

Maximum Permissible Concentration MSIV - Main Steam Isolation Valve NIOSH - National Institute for Occupational Safety and Health PCI - Primary Containment Isolation PCIOMR - Preconditioning Interim Operating Management Recommendations RBCCH - Reactor Building Closed Cooling Hater System RBH -

Rod Block Monitor RCIC - Reactor Care Isolation Cooling System RHRS - Residual Heat Removal System RPS - Reactor Protection System RHM -

Rod Horth Minimizer SBGTS - Standby Gas Treatment System S8LC - Standby Liquid Control SDC - Shutdown Cooling Mode of RHRS SDV - Scram Discharge Volume SRM - Source Range Monitor TBCCH - Turbine Building Closed Cooling Hater Sjstem TIP - Traversing Incore Probe TSC - Technical Support Center 0027H/0061Z

Commonwealth Edison ouad Cities Nuclear Power Station 22710 206 Avenue North Corcova, Illinois 61242 Telephone 309/654-2241 RAR-88-14 April 1, 1988 U.S. NRC Office of Nuclear Reactor Regulation Washington, D. C. 20555 Attn: Document Control Desk Enclosed for your information is the Monthly Performaiice Report covering the operation of Quad-Cities Nuclear Power Station, Units One and Two, durir.g the month of March,1988.

Respectfully, COMHONHEALTH EDISON COMPANY QUAD-CITIES NUCLEAR POWER STATION R.A.Robey%

Services Superintendent vk Enclosure l

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0027H/0061Z